2. 2
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Schedule
Well completion Sequences
Well life Cycle and well handover
Completion types and design criteria
Well clean up and completion fluid switch over
Perforation, Gamma ray CCL depth correlation
Running completion string
Running completion string
Nipple Up X-mass tree
Nipple Up X-mass tree
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P/U & M/U CSG string
Well Drilling
▪ Pull up casing pipes to rig floor
▪ Make-up string pipes together.
▪ RIH with casing string to require depth to
cover the borehole.
19. 19
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Hanger landing 9 5/8” Casing
Well Drilling
• Hanger landing.
• Set Casing Hanger & space out.
• Suspends intermediate or production casing string
• Centers the casing string in the head (or spool)
• Seals off the casing annulus
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Cement bond log CBL
Well Drilling
◉ Sonic Path in Cased Hole
◉ CBL measures casing to cement bond
◉ Bond logs are run to determine:
1. Cement to casing relationship
2. Cement to formation relationship
3. Evaluate cement conditions:
• Channeling
• Compromised cement (i.e. gas cut, dehydrated, etc.)
• Cement stages
• Cement top
• Micro annulus
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Open hole logging
Well Drilling
A well log is the record of one or more
physical measurements as a function of
depth in a borehole.
Well logs are recorded by instruments
(sondes or tools) carrying sensors,
which are lowered into a well bore by a
cable (wire line logs) or directly connected
to the drilling pipes (while drilling logs).
◉ Well logging
33. 33
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Open hole logging
Well Drilling
1. Open hole log
2. Cased hole log
◉ Well logging
To estimate Hydrocarbon
potential of a reservoir, we need
to know :
• Porosity
• Permeability
• Water Saturation
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Open hole logging
Well Drilling
Caliper
Gamma ray Bulk Density
+.25
-.25 0
Correction
Grams/CC
Grams/CC
Hole diam. in inches
Depths
API units
6 16
10
0 3.0
2.0 2.5
Mud Wt. 10 lb/gal
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Well Completion
Completion cost
Well Completion
£
£
£
£
€
€
€
€
Completion fluid additives,
completion liner and tubing
wellhead equipment completion and perforating crews
pumping equipment rentals
completion costs generally fall in the
range of $2.9 MM to $5.6 MM per well
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Well Completion
Completion operation
Well Completion
Well Completion
✘ The objective of a completion is to convey fluids from the
reservoir to the surface, in a safe and efficient manner.
Process include:
✘ The design, Selection and installation of tubular, tools and
equipment, located in the wellbore, for the purpose of
conveying, pumping or controlling production (or injection)
fluids.
◈ Protect the Casing and Contain the Reservoir fluids
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Well Completion
Wellbore CLEAN UP
Well Completion
• Run a bit and scraper to bottom to clean
casing from mill scale and cement.
❑ A bit and scraper assembly to be RIH.
• The purpose of this trip is to clean
out any excess cement within the
casing, and particularly to remove
any cement that may be on the
casing wall at the packer setting
depth.
CASING
SCRAPER
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Well Completion
Circulating the well bottom up
Well Completion
• The quality of the fluid used during a
completion and workover operation
should be guaranteed to avoid any
problem during production phase.
• Displace all drilling fluid with a completion fluid
(brine) after cementing production casing
or liner.
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Well
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Well Completion
Circulating the well bottom up
Well Completion
❑ A clear, solids free fluid that is displaced
into the hole prior to running the
completion.
❑ They differ from normal drilling muds in
minimizing the formation damage to the
production zone but at the same time
maintain circulating capacity and well
control.
❑ Brine (salts: KCl, NaCl, MgCl2, CaBr2, ZnBr2,
etc)
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Well Completion
Completion Fluids
Well Completion
❑ The primary performance requirement for a completion fluid is hydrostatic
pressure control.
❑ The density must be sufficient to produce a hydrostatic pressure in the
wellbore to control formation pressures.
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Well Completion
Clean-Out BHA
Well Completion
1. 6’’ bit - DEA
2. 7’’ scraper – Baker Oiltools
3. 7’’ junk basket – Baker Oiltools
4. 7’’ string magnet – Baker Oiltools
5. 7’’ brushes – Baker Oiltools
6. 1 x 3 ½’’ DP – Rig 94
7. 7’’ Halliburton RTTS Test packer – Halliburton
8. Circ. Valve – Halliburton
9. 4 ¾’’ DC – Rig 94
10. X-O – BakerOiltools ?? / WOOD International ?? NC35 Pin x 4 ½’’ PH6 Box
11. 4 ½’’ PH6 Tbg. – Wood International
12. X-O – BakerOiltools ?? / WOOD International ?? 4 ½’’ PH6 Pin X 4 ½’’ IF Box
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Well Completion
Clean-Out BHA
Well Completion
Wellbore Cleanup BHA
Description
Conn.
Up
Conn.
Dwn.
O.
D.
I.
D.
Tool
Length
Top
of
Tool
Bottom
of Tool
RIG Drill Pipes BH6 BH6 4 1/2'' 3 1/2'' 2692.75 0.62 2693.37
RIG Cross Over BH6 3 1/2'' IF P 1 2693.37 2694.37
BAKER Flex Sub 3 1/2'' IF B 3 1/2'' IF P 4 3/4'' 1 3/4'' 0.605 2694.37 2694.97
BAKER 9-5/8" Multi-Task Wellbore Filter 3 1/2'' IF B 3 1/2'' IF P 6'' 1 5/8'' 5.855 2694.97 2700.83
BAKER 9-5/8" Ultra-Clean Casing Brush 3 1/2'' IF B 3 1/2'' IF P 6''' 1 1/2'' 3.145 2700.83 2703.97
BAKER 9-5/8" Grabitz Magnet 3 1/2'' IF B 3 1/2'' IF P 6'' 2'' 3.544 2703.97 2707.52
BAKER 7'' Non Rotating Scrapper 3 1/2'' IF B 3 1/2'' IF P 6'' 1 5/8'' 3.145 2707.52 2710.66
BAKER Bit Sub 3 1/2'' IF B 3 1/2'' Reg. B 4 3/4'' 1 5/8'' 0.425 2710.66 2711.09
BAKER Junk Mill 3 1/2'' Reg / 5 7/8'' 1 1/2'' 0.915 2711.09 2712.00
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Well Completion
Perforation techniques
Well Completion
• There are currently three standard methods of perforating a well using
shaped charges:
• Casing gun perforating (run on wireline)
• Through-tubing perforating (TTP) (run on wireline)
• Tubing-conveyed perforating. (TCP) (run on tubing)
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Well Completion
Pip tag
Well Completion
Pip tag
A radioactive tag in a sub is installed in the string
within the proximity of the packer.
This sub is used as a marker when performing the
GR/CCL. If the formation has little GR character,
radioactive collars can also be included in the casing
string for definitive depth control.
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Well Completion
Running completion string
Well Completion
◉ Completion string The primary conduit
through which reservoir fluids are
produced to surface. The production
string is typically assembled with tubing
and completion components in a
configuration that suits the wellbore
conditions and the production method.
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Well Completion
Completion Equipment
Well Completion
Upper
completion Sliding Side Door
Landing Nipple
Retrievable Packer
Perforated Joint
Landing Nipple
Landing Nipple
Mule Shoe Guide
Protection Joint
Tubing Hanger
SCSSV
Side Pocket Mandrel
Side Pocket Mandrel
Tubing
Flow Coupling
Flow Coupling
Tubing
lower
completion
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Well Completion
Completion Equipment
Well Completion
Applications
▪ sub-surface tool used to provide a seal between the Tubing and Casing
▪ thus preventing the movement of fluids past this sealing point.
Functions
1. Protect casing from bursting
2. Protect casing from corrosion
3. Provide better well control.
4. Prevent fluid movement between pay zones.
5. Isolate zones of bad cement Perforation
Tail pipe
Packer
Annulus
With
packer fluid
Casing
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Well Completion
Packer Components
Well Completion
Components
◉ Production packer
Slips
01
• Tooth-like parts of the packer
• Forced outward by sitting action
• Top slips to prevent up-motion and bottom for down-motion
Packing elements
02
Slips
Packing element
• Nitrile-rubber for moderate temperature and normal pressure
or Elastomers for HTHP
• Provide seal between CSG and TBG
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Well Completion
Packer Components
Well Completion
Types
◉ Production packer
Permanent
01
• Permanently set
• Cannot be retrieved except by milling
Retrievable
02
• RIH on wireline or tubing
• Has bi-directional slips prevent debris from setting on bottom
• Main advantage is retrieving without destroying
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No bore – bridge plug
Single Bore
Duel Bore
◎ Used to isolate casing or tubing
◎ Used as cement retainers
◎ Used when other plugs fail to set (last resort!)
◎ Used for single completions
◎ Used for dual completions
Packer Setting Mechanism
Well Completion
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Tubing Functions
Well Completion
Casing
Tubing
No-Go
Nipple.
Perfs
• A wellbore tubular used to produce
reservoir fluids. Production tubing
is assembled with other completion
components to make up the
production string.
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Tubing Specifications
Well Completion
Tubing Grade
Term used to describe the type of metal alloy of which the pipe is made.
Selection of tubing grade is based on:
▪ Physical strength
▪ Design life
▪ Chemical Properties (resistance to H2S, CO2, water etc.)
▪ Availability and standardization at customer
▪ Cost
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Tubing Specifications
Well Completion
Tubing Grade
Steel grade: there are mainly two different types of steel used to manufacture tubing:
▪ API standard steels J55, C75, L80, N80, C90 and P105.
1. The letter represent the chemical composition and sometimes the thermal treatment.
2. The number following the letter is the minimum body yield stress in 1000 psi and it is
the minimum body yield stress guaranteed by the manufacturer’s.
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Tubing Specifications
Well Completion
Tubing Grade
Steel grade: there are mainly two different types of steel used to manufacture tubing:
▪ Stainless steel, alloys, and special pipe When carbon dioxide and/or hydrogen sulfide
are part of the produced fluids, it could necessary to use stainless steel, alloys, and special
pipe.
▪ For Example
• 9 Cr is used for H2S applications.
• 13 Cr for CO2: 13% chromium is selected when there is no H2S in addition to
the CO2.
• 22 Cr for CO2 + H2S: 22-25% chromium steel when the H2S partial pressure
is not too high (some psi).
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Production Tubing
Tubing Diameter
Refers to the outside diameter (in inches or millimeters)
Tubing is measured by the OUTSIDE DIAMETER (O.D.), specified in inches (e.g., 1.250) or
fraction of an inch (eg. 1-1/4″).
The most used sizes are: 2-⅜”, 2-⅞”, 3-½” and 4-½”
Nominal Size
(inches)
Weight
per foot
ID
(inches)
Drilling Drift
(inches)
Wireline Drift
(inches)
2 3/8 4.70 1.995 1.901 1.875
2 7/8 6.50 2.441 2.347
2.313
3 1/2 9.30 2.992 2.867 2.750
4 1/2 12.75 3.958 3.883 3.813
5 1/2 15.50 4.919 4.825 4.750
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Production Tubing
Tubing weight
is the average weight of the tubing, connection included.
Expressed in lb/ft.
It determines the tubing wall thickness, Corrosion/erosion resistance, Strength, Cost
The most common nominal weights are:
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Tubing are screwed together through connections,
which could be:
1. by means of integral joint, the most
common type of connection on small
diameter pipe.
Production Tubing
Tubing Connections
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Tubing are screwed together through connections,
which could be:
2. by using a coupling (the most common
connection), a collar with internal
threads used to join two sections of
threaded pipe.
Production Tubing
Tubing Connections
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Production Tubing
Tubing Connections
The types of pipe threads specified by the API for casing
and tubing include:
• NEW VAM
• VAM TOP
• Hydril
• Short Thread Coupled (STC)
• Long Thread Coupled (LTC)
• Buttress Thread Coupled (BTC)
• Line Pipe (LP)
• External Upset End (EUE)
• Non-Upset End (NUE)
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Production Tubing
Tubing Design
Design of production tubing should satisfy the following criteria:
1. Minimizing pressure drop
2. High strength for suspension of tubing joints
3. High internal pressures for fluids flow
4. High external pressures (between annulus & tubing)
5. Resistant to chemical corrosion
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Production Tubing
Tubing Length
II. Length:
Tubulars are manufactured in lengths termed joints
✓ range 1 : 20 to 24 feet;
✓ range 2 : 28 to 32 feet;
✓ range 3 : 32 to 48 feet
Pup joints or spacers are used for shorter lengths.
Tubing Ranges
Range 1 (feet) Range 2 (feet) Range 3 (feet)
20-24 28-32 38-42
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Landing Nipples
Applications
▪ A landing nipple is a short length of pipe with a profile cut
on the inside of the pipe.
▪ Provide a location for wireline tools to be hanged in place in
locations which are carefully considered during installation
Types
X Selective Nipples XN No-go nipples
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Landing Nipples
Applications
▪ Plug the tubing for:
• Removing the wellhead or surface equipment
• Pressure testing
• Setting hydraulic set packers
• Zonal isolation
▪ Installing downhole chokes, regulators, SSVs, etc.
▪ landing off bottom hole pressure recorders.
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Landing Nipples
No – go nipple XN
• XN®, RN®, Nipples (N = no-go) contain a restriction in the profile
which prevents the Slickline plug from passing through.
• Only 1 no-go nipple of a particular size is used in a well and
usually it will be placed at or near the bottom of the well below
other landing nipples.
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Landing Nipples
Design Specifications
LOCK PROFILE XN
SIZE 2.813 INCH
MAXIMUM OD 3.919 INCH
MINIMUM NO-GO ID 2.666 INCH
LENGTH 17.71 INCH
MATERIAL Alloy/9CR / 13CR
SERVICE H2S/CO2/ STD
CONNECTION 3 ½” Vam Top B * P
PRESSURE RATING 9300 PSI
CN05527
Max OD: 3.898”
Packing Bore ID: 2.813”
Min ID: 2.813”
Nipple Profile: X
Length: 18.50”
Top Thread: 3 1/2-9.2 FOX-K Box
Bottom Thread: 3 1/2-9.2 FOX-K Pin
Material: 13Cr
Service: Std
Pres. Rating: 9300 psi
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B. Flow Coupling.
Well Completion
▪ Flow couplings are short sections of thicker
walls than the production tubing.
▪ designed to protect the tubing string from
excessive wear and premature failure.
▪ Added protection against internal erosion
▪ above and below cross-overs,
▪ above and below a landing nipple, SSSV
nipple, etc.
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C. Blast Joint.
Well Completion
Applications
▪ Located in the tubing string in front of to perforations (ID same as
tubing).
▪ Blast joints are heavy wall tubular accessories that are typically run in
sections of the string design where oil or gas returns in the tubing will
encounter turbulence. They provide an increased wall thickness to
prevent failures caused by turbulent erosion in the ID of the tubing.
1. Tungsten
2. Rubber
3. Ceramic
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D. Side Sliding Door SSD
Well Completion
◉ Application:
known as Sliding Sleeves
Allows communication from the
annulus to the tubing.
Used for Circulation of casing to
inside tubing incase of well killing
or production.
Sliding Side
Door (SSD)
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D. Side Sliding Door SSD
Well Completion
Sliding (inner)
Sleeve
Seals
Ports
Seals
Inner Ports
OPEN CLOSED
◉ Application:
Fluid displacement
Well killing (by fluid circulation)
Kicking off wells (gas lift)
Chemical injection.
Commingled production.
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E. Subsurface Safety Valves SCSSSV
Well Completion
Piper Alpha tragedy
Piper Alpha was an oil production platform in
the North Sea.
on 6 July 1988, killing 167 people.
Catastrophic platform accident due to
explosion in process facility and release of gas
in pipeline.
Almost all of the wells controlled below seabed
with SC-SSSVs!.
Only well that burnt was being worked over –
no SSSV in place.
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E. Subsurface Safety Valves SCSSSV
Well Completion
Kuwait oil well fires
• Persian Gulf War. 1991
• The Kuwaiti oil fires were caused
by Iraqi military forces setting fire
to a reported 605 to 732 oil wells
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E. Subsurface Safety Valves SCSSSV
Well Completion
◉ Application
A shutdown valve installed at the
upper wellbore for emergency
shutdown
To prevent uncontrolled release of
hydrocarbons from the well if
something catastrophic occurs at
surface.
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E. Subsurface Safety Valves SCSSSV
Well Completion
Subsurface Safety Valves SCSSSV
Setting Depth
❖ Offshore
Normally installed 200 to 300 ft below
seabed or as deep as possible
❖ Onshore
The SCSSV is located a minimum of 100 ft
below the mudline.
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SCSSSV
❖ Shallow set valves reduce the exposed hydrocarbon inventory.
❖ Deep-set valves have less opportunity to be affected by catastrophic events
❖ Safety valves should not be placed in areas exposed to continuous scaling, wax
or hydrate formation.
Recommended minimum setting depth
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SCSSSV
Running Wireline retrievable (WLRSV) Tubing Retrievable (TRSV)
▧ General application: where
intervention by wireline is
available
▧ High pressure gas wells
▧ Deployed on a wireline
running tool to be installed in
an appropriate landing nipple.
▧ Advantage: can be replaced by
wireline
▧ Disadvantage: a significant
restriction in flow path.
▧ General application: where
larger flow area is desired for
the tubing size
▧ Advantage: maximum
opening and minimum
restriction to flow. Allows
some wireline and CT access
capability.
▧ Disadvantage: must pull
tubing to repair.
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SCSSSV Annulus SV
W/L Retrievable Tub. Retrievable
Surface Controlled
Hydraulic
Control line
Tubing SV
W/L Retrievable Tub. Retrievable
Surface Controlled
Sub-S Controlled
Hydraulic
Wireless
Cable
Control line
Annulus
Electric
Excess flow Pressure drop
Ball Flapper
Application
Running
Means of Activation
Communication route
Open & Close Element Poppet
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Subsurface Safety Valves SCSSSV
Control line
• The hydraulic control line, also known as a
chemical injection line, is a small-diameter
line, usually ⅛ in. (32 mm) or ⅝ in. (16 mm)
• Used to execute tool recovery, perform
chemical injection, and operate downhole
completions equipment such as surface-
controlled subsurface safety valves (SCSSV).
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SCSSSV
Control line connection to downhole safety valve
• A 1/4″ inch stainless steel control line is attached
• It may be necessary to keep as much as 4000 to
5000 psi on the control line to keep the valve open.
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SCSSSV
Flapper Types
• Initially, flapper / seat combinations are capable of
sealing 15,000 psi + (bubble tight).
• hydraulic pressure from the surface opposes the
mechanical spring pressure and holds the valve open
• The flapper valve can further be divided in flat,
contoured and curved flappers,
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T e r m i n o l o g y
Working Pressure
Wellhead equipment that meets API Specification 6A (equivalent to ISO 10423) is
available in standard pressure increments:
• 2000 psi
• 3000 psi
• 5000 psi
• 10,000 psi
• 15,000 psi
• 20,000 psi
• 30,000 psi
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T e r m i n o l o g y
Working Temperature
❑ Conventional operations span -60
to 121⁰C in 8 ranges (K, L, P, R,
S, T, U,V). K and U are the largest
and overlap the other ranges.
❑ Elevated temperature operations
span -18 to 345⁰C in 2 ranges (X,
Y). Y has the highest temperature
rating.
Standard temperature ratings are defined by an operating range.
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T e r m i n o l o g y
Material Class
Defines the corrosion resistance required by all components wetted by the
retained fluid.
❑ The seven material classes range from AA (General service: carbon or low
alloy steel) to HH (Sour service: corrosion resistant alloys).
❑ All sour service materials must conform to ANSI/NACE MR0175/ISO 15156
(NACE International provides control standards related to corrosion
protection).
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C o n n e c t i o n S e a l s
Seals Technology
Connection Seals
Ring Gaskets
❖ provides the actual seal in
any flanged or studded
connection,
❖ The ring gasket is
machined, metal seal
designed to fit the
grooves on each flange or
hub face.
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Christmas Tree
The Christmas tree is pressure
control system located at the
well head.
A Xmas Tree is an assembly of
valves, all with specific
functions, used to control flow
from the well and to provide
well intervention access for
well maintenance or reservoir
monitoring.
X-Mass tree Components
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Upper Master Valve
Usually operated to open and
close the wellbore. This valve is
often fitted with an actuator so
that the valve can be
controlled remotely.
X-Mass tree Valves
Kill Wing Valve
Production Wing
Valve
Choke Valve
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Eng.Elsayed Amer
Swab Valve
kept closed during flowing of
the well and is opened to allow
access into the tubing string
when maintenance of the
tubing string is required.
X-Mass tree Valves
Kill Wing Valve
Production Wing
Valve
Choke Valve
184. Eng.Elsayed Amer
P
A
G
E
184
Well
completion
Eng.Elsayed Amer
Production wing Valve
Used in conjunction with the
upper master valve in
controlling the well. This valve
is normally fitted with an
actuator similar to that of the
upper master valve so that the
valve can be controlled
remotely.
X-Mass tree Valves
Kill Wing Valve
Production Wing
Valve
Choke Valve
187. Eng.Elsayed Amer
P
A
G
E
187
Well
completion
Eng.Elsayed Amer
Choke Valve
Attached to the downstream
side of the flowline wing valve,
the choke is used to control or
regulate the flow of produced
fluids.
The choke can be of varying
styles, positive, adjustable or
multi-orifice and in some
instances may be fitted with a
remote actuator.
X-Mass tree Valves
Kill Wing Valve
Production Wing
Valve
Choke Valve
189. Eng.Elsayed Amer
P
A
G
E
189
Well
completion
Tubing Hanger
Back pressure valves
Seal
Handling
Thread
Hanger
Thread
Valve Spring
Valve
Stem
BPV TWC
What is it used for?
Back pressure valves are installed in the tubing
hanger to hold pressure from below during the
following operations:
1. Nipple down and up the drilling BOP stack.
2. Nipple up or down Christmas tree.
3. Test the Christmas tree (2-way check).
4. Replace the master valve.